Second-Quarter 2020 Earnings Presentation
Forward-Looking / Cautionary Statements This presentation, including any oral statements made regarding the contents of this presentation, including in the conference call referenced herein, contains forward-looking statements as defined under Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, that address activities that Laredo Petroleum, Inc. (together with its subsidiaries, the “Company”, “Laredo” or “LPI”) assumes, pl ans, expects, believes, intends, projects, indicates, enables, transforms, estimates or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. The forward- looking statements are based on management’s current belief, based on currently available information, as to the outcome and timing of future events. General risks relating to Laredo include, but are not limited to, the decline in prices of oil, natural gas liquids and natural gas and the related impact to financial statements as a result of asset impairments and revisions to reserve estimates, oil production quotas or other actions that might be imposed by the Organization of Petroleum Exporting Countries and other producing countries (“OPEC+”), the outbreak of disease, such as the coronavirus (“COVID - 19”) pandemic, and any related government policies and actio ns, changes in domestic and global production, supply and demand for commodities, including as a result of the COVID-19 pandemic and actions by OPEC+, long-term performance of wells, drilling and operating risks, the increase in service and supply costs, tariffs on steel, pipeline transportation and storage constraints in the Permian Basin, the possibility of production curtailment, hedging activities, possible impacts of litigation and regulations, the impact of repurchases, if any, of securities from time to time, and other factors, including those and other risks described in its Annual Report on Form 10-K for the year ended December 31, 2019, Amendment No. 1 to its Quarterly Report on Form 10-Q for the quarter ended March 31, 2020, its Quarterly Report on Form 10-Q for the quarter ended June 30, 2020 and those set forth from time to time in other filings with the Securities and Exchange Commission (“SEC”). These documents are available through Laredo’s website at www.laredopetro.com under the tab “Investor Relations” or through the SEC’s Electronic Data Gathering and Analysis Retrieval System at www.sec.gov. Any of these factors cou ld cause Laredo’s actual results and plans to differ materially from those in the forward-looking statements. Therefore, Laredo can give no assurance that its future results will be as estimated. Any forward-looking statement speaks only as of the date on which such statement is made. Laredo does not intend to, and disclaims any obligation to, correct, update or revise any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law. The SEC generally permits oil and natural gas companies, in filings made with the SEC, to disclose proved reserves, which are reserve estimates that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditio ns and certain probable and possible reserves that meet the SEC’s definitions for such terms. In this press release and the conference call, the Company may use the terms “resource potential,” “resource play,” “estimated ultimate recovery,” or “EURs,” and “type curve” each of which the SEC guidelines restrict from being included in filings with the SEC without strict compliance with SEC definitions. These terms refer to the Company’s internal estimates of unbooked hydrocarbon quantities that may be potentially discovered through exploratory drilling or recovered with additional drilling or recovery techniques. “Resource potential” is used by the Company to refer to the estimated quantities of hydrocarbons that may be added to proved reserves, largely from a specified resource play potentially supporting numerous drilling locations. A “resource play” is a term used by the Company to describe an accumulation of hydrocarbons known to exist over a large areal e xpanse and/or thick vertical section potentially supporting numerous drilling locations, which, when compared to a conventional play, typically has a lower geological and/or commercial development risk. EURs are based on the Company’s previous operating experience in a given area and publicly available information relating to the operations of producers who are conducting operations in these areas. Unbooked resource potential or EURs do not constitute reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System or SEC rul es and do not include any proved reserves. Actual quantities of reserves that may be ultimately recovered from the Company’s interests may differ substantially from those presented herein. Fac tors affecting ultimate recovery include the scope of the Company’s ongoing drilling program, which will be directly affected by the availability of capital, decreases in oil, natural gas liquids and natural gas prices, well spacing, drilling and production costs, availability and cost of drilling services and equipment, drilling results, lease expirations, transportation constraints, regulatory approvals, negative revisions to reserve estimates and other factors as well as actual drilling results, including geological and mechanical factors affecting recovery rates. EURs from reserves may change sig nificantly as development of the Company’s core assets provides additional data. In addition, our production forecasts and expectations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells and the undertaking and outcome of future drilling activity, which may be affected by significant commodity price declines or dr illing cost increases. “Type curve” refers to a production profile of a well, or a particular category of wells, for a specific play and/or area. In addition, the Company’s production forecasts and expec tations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells and the undertaking and outcome of future drilling activity, which may be affected by significant commodity price declines or drilling cost increases. The “standardized measure” of discounted future new cash flows is calculated in accordance with SEC regulations an d a discount rate of 10%. Actual results may vary considerably and should not be considered to represent the fair market value of the Company’s proved reserves. This presentation includes financial measures that are not in accordance with generally accepted accounting principles (“GAAP”), including Adjusted EBITDA, Cash Flow and Free Cash Flow. While management believes that such measures are useful for investors, they should not be used as a replacement for financial measures that are in accordance with GAAP. For a reconciliation of Adjusted EBITDA, Cash Flow and Free Cash Flow to the nearest comparable measure in accordance with GAAP, please see the Appendix. Unless otherwise specified, references to “average sales price” refer to average sales price excluding the effects of our der ivative transactions. All amounts, dollars and percentages presented in this presentation are rounded and therefore approximate. 2
Successfully Operating in a Turbulent Macro Environment 2Q-20 Select Results vs Guidance 1 Oil Production Lease Operating Expense Controllable Cash Costs Production 31.2 MBO/d $2.40/BOE 2% beat vs guidance 16% beat vs guidance G&A (Excluding LTIP) Total Production $1.02/BOE 94.1 MBOE/d 10% beat vs guidance 27% beat vs guidance Financial & Operational Highlights Maintained Realized $87 MM Reduced flared / Increased FY-21 drilling in matured vented gas to oil hedges to efficiencies commodity only 1.1% of total 70% of expected during transition derivative natural gas production 2 to Howard County settlements production 3 1 Utilizes high end of guidance where applicable 2 Hedges executed through 8-4-20
Strategy to Increase Stakeholder Value Foundation Manage Optimize Financial Risk Existing Assets Expand High- Consolidate to Margin Inventory Increase Scale Objectives Improve Target Free Reduce Expand Cash Flow 1 oil cut leverage margins 4 1 See Appendix for reconciliations of non-GAAP measures
Howard County Oil Productivity Drives Returns 100% 80% ROR 1 (%) 60% 40% 20% LPI Leasehold 0% Howard County Relevant $35 $40 $45 $50 Offset Wells WTI ($/Bbl) Howard County Relevant Offset LPI Howard County Budget Howard County Relevant Offset Cumulative Oil Production Compared to Established Acreage 250 Production (MBO) Cumulative Oil 200 150 100 50 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 0 Months Howard County Relevant Offset Oil Production 2 LPI Howard County Budget LPI Established Acreage Regional Cline Oil Type Curve LPI Established Acreage UWC/MWC Oil Type Curve Expect to complete first 15-well package in Howard County during 4Q-20 1 Returns are based on $5.5 MM well costs; applicable natural gas strip pricing details can be found in the Appendix 5 2 Howard County Relevant Offset cumulative oil production normalized to time 0 start and 10,000’, courtesy of Enverus (as of 10-28-19) Note: Map as of 06-30-20
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